Calgary, Canada
Calgary, Canada

Time filter

Source Type

News Article | April 17, 2017
Site: www.marketwired.com

CALGARY, ALBERTA--(Marketwired - April 17, 2017) - Enbridge Income Fund Holdings Inc. (TSX:ENF) (the Company) announced today that its Board of Directors has declared a cash dividend of $0.1711 per common share (Share) to be paid on May 15, 2017 to shareholders of record at the close of business on May 1, 2017. This dividend is designated eligible dividends for Canadian tax purposes that qualify for the enhanced dividend tax credit. Eligible shareholders may participate in the Company's Dividend Reinvestment Plan ("DRIP"), where they may elect, without brokerage fees, to automatically reinvest their dividends in additional Shares at a 2% discount to the Share price. Details of the DRIP are available on the Company's website. Shareholders who wish to participate in the DRIP should contact their investment dealer for further information and to enroll. The Shares trade on the TSX under the symbol ENF. Enbridge Income Fund Holdings Inc. is a publicly traded corporation. The Company, through its investment in Enbridge Income Fund indirectly holds high quality, low- risk energy infrastructure assets. The Fund's assets consist of a portfolio of Canadian liquids transportation and storage businesses, including the Canadian Mainline, the Regional Oil Sands System, the Canadian segment of the Southern Lights Pipeline, Class A units entitling the holder to receive defined cash flows from the US segment of the Southern Lights Pipeline, a 50 percent interest in the Alliance Pipeline, which transports natural gas from Canada to the U.S., and interests in more than 1,400 MW of renewable and alternative power generation assets. Information about Enbridge Income Fund Holdings Inc. is available on the Company's website at www.enbridgeincomefund.com.


News Article | May 3, 2017
Site: www.marketwired.com

CALGARY, ALBERTA--(Marketwired - May 3, 2017) - Veresen Inc. ("Veresen") (TSX:VSN) is pleased to announce that at its annual meeting of shareholders held in Calgary, Alberta on May 3, 2017, all the nominees listed in its notice of meeting and information circular dated March 14, 2017, were elected as directors of Veresen, the results being as follows: Veresen is a publicly-traded dividend paying corporation based in Calgary, Alberta that owns and operates energy infrastructure assets across North America. Veresen is engaged in three principal businesses: a pipeline transportation business comprised of interests in the Alliance Pipeline, the Ruby Pipeline and the Alberta Ethane Gathering System; a midstream business which includes a partnership interest in Veresen Midstream Limited Partnership which owns assets in western Canada, and an ownership interest in Aux Sable, which owns a world-class natural gas liquids (NGL) extraction facility near Chicago, and other natural gas and NGL processing energy infrastructure; and a power business comprised of a portfolio of assets in Canada. Veresen is also developing Jordan Cove LNG, a 7.8 million tonne per annum natural gas liquefaction facility proposed to be constructed in Coos Bay, Oregon, and the associated Pacific Connector Gas Pipeline. In the normal course of business, Veresen regularly evaluates and pursues acquisition and development opportunities. Veresen's Common Shares, Cumulative Redeemable Preferred Shares, Series A, Cumulative Redeemable Preferred Shares, Series C, and Cumulative Redeemable Preferred Shares, Series E trade on the Toronto Stock Exchange under the symbols "VSN", "VSN.PR.A", "VSN.PR.C" and "VSN.PR.E", respectively. For further information, please visit www.vereseninc.com.


CALGARY, ALBERTA--(Marketwired - April 21, 2017) - Enbridge Income Fund Holdings Inc. (TSX:ENF) will hold its Annual Meeting of Shareholders in Calgary, Alberta on Thursday, May 11, 2017. A live audio webcast of the Annual Meeting will be available at enbridgeincomefund.com/agmwebcast. A webcast replay will be available on the Company's website approximately two hours following the event. An mp3 and transcript will be posted to the website shortly thereafter. Members of the media interested in attending the meeting in person are asked to please register in advance by calling the Enbridge Media Line at 888-992-0997. For additional information on the Annual Meeting of Shareholders, including voting and attendance procedures please refer to enbridgeincomefund.com/agminfo. Enbridge Income Fund Holdings Inc. is a publicly traded corporation. EIFH, through its investment in Enbridge Income Fund indirectly holds high quality, low-risk energy infrastructure assets. Enbridge Income Fund's assets consist of a portfolio of Canadian liquids transportation and storage businesses, including the Canadian Mainline, the Regional Oil Sands System, the Canadian segment of the Southern Lights Pipeline, Class A units entitling the holder to receive defined cash flows from the US segment of the Southern Lights Pipeline, a 50 percent interest in the Alliance Pipeline, which transports natural gas from Canada to the U.S., and interests in more than 1,400 MW of renewable and alternative power generation assets. Information about Enbridge Income Fund Holdings Inc. is available on EIFH's website at www.enbridgeincomefund.com.


Botros K.K.,Nova Chemicals Corporation | Geerligs J.,Nova Chemicals Corporation | Rothwell B.,Brian Rothwell Consulting Inc. | Carlson L.,Alliance Pipeline Ltd. | And 2 more authors.
International Journal of Pressure Vessels and Piping | Year: 2010

The control of propagating ductile (or tearing) fracture is a fundamental requirement in the fracture control design of pipelines. The Battelle two-curve method developed in the early 1970s still forms the basis of the analytical framework used throughout the industry. GASDECOM is typically used for calculating decompression speed, and idealizes the decompression process as isentropic and one-dimensional, taking no account of frictional effects. While this approximation appears not to have been a major issue for large-diameter pipes and for moderate pressures (up to 12 MPa), there have been several recent full-scale burst tests at higher pressures and smaller diameters for which the measured decompression velocity has deviated progressively from the predicted values, in general towards lower velocities. The present research was focused on determining whether pipe diameter was a major factor that could limit the applicability of frictionless models such as GASDECOM. Since potential diameter effects are primarily related to wall friction, which in turn is related to the ratio of surface roughness-to-diameter, an experimental approach was developed based on keeping the diameter constant, at a sufficiently small value to allow for an economical experimental arrangement, and varying the internal roughness. A series of tests covering a range of nominal initial pressures from 10 to 21 MPa, and involving a very lean gas and three progressively richer compositions, were conducted using two specialized high-pressure shock tubes (42 m long, I.D. = 38.1 mm). The first is honed to an extremely smooth surface finish, in order to minimize frictional effects and better simulate the behaviour of larger-diameter pipelines, while the second has a higher internal surface roughness. The results show that decompression wave speeds in the rough tube are consistently slower than those in the smooth tube under the same conditions of mixture composition and initial pressure & temperature. Preliminary analysis based on perturbation theory and the fundamental momentum equation indicates that the primary reason for the slower decompression wave speed in the rough tube is the higher spatial gradient of pressure pertaining to the decompression wave dynamics, particularly at lower pressure ratios and higher gas velocities. The magnitude of the effect of the slower decompression speed on arrest toughness was then evaluated by a comparison involving several hypothetical pipeline designs, and was found to be potentially significant for pipe sizes DN 450 and smaller. © 2010 Elsevier Ltd.


Botros K.K.,Nova Chemicals Corporation | Carlson L.,Alliance Pipeline Ltd. | Reed M.,Alliance Pipeline Ltd.
International Journal of Pressure Vessels and Piping | Year: 2013

The decompression wave speed, which is used throughout the pipeline industry in connection with the Battelle two-curve method for the control of propagating ductile fracture, is typically calculated using GASDECOM (GAS DECOMpression). GASDECOM, developed in the 1970's, idealizes the decompression process as isentropic and one-dimensional, taking no account of pipe wall frictional effects or pipe diameter. Previous shock tube tests showed that decompression wave speeds in smaller diameter and rough pipes are consistently slower than those predicted by GASDECOM for the same conditions of mixture composition and initial pressure and temperature. Previous analysis based on perturbation theory and the fundamental momentum equation revealed a correction term to be subtracted from the 'idealized' value of the decompression speed calculated by GASDECOM. One parameter in this correction term involves a dynamic spatial pressure gradient of the outflow at the rupture location. While this is difficult to obtain without a shock tube or actual rupture test, data from 14 shock tube tests, as well as from 14 full scale burst tests involving a variety of gas mixture compositions, were analyzed to correlate the variation of this pressure gradient with two characteristics of the gas mixture, namely; the molecular weight and the higher heating value (HHV). For lean to moderately-rich gas mixes, the developed semi-empirical correlation was found to fit very well the experimentally determined decompression wave speed curve. For extremely rich gas mixes, such as High Heating Value Processed Gas (HHVPG) mixtures of HHV up to 58MJ/m3, it was found that it overestimates the correction term. Therefore, additional shock tube tests were conducted on (HHVPG) mixes, and the previously developed semi-empirical correlation was extended (revised) to account for such extremity in the richness of the gas mixtures. The newly developed semi-empirical correlation covers a wider range of natural gas mixtures from as lean as pure methane up to HHVPG mixtures of HHV=58MJ/m3. © 2013 Elsevier Ltd.


Sahney R.,PBoK Technical Training Ltd. | Reed M.,Alliance Pipeline Ltd. | Skibinsky D.,Alliance Pipeline Ltd.
Proceedings of the Biennial International Pipeline Conference, IPC | Year: 2014

The Canadian Energy Pipeline Association (CEPA) is a voluntary, non-profit industry association representing major Canadian transmission pipeline companies. With the advent of changes in both CSA Z6621 as well as the National Energy Board Onshore Pipeline Regulations (OPR)2, the membership determined a Recommended Practice regarding a Management Systems Approach for Facilities Integrity was needed. As such, the Pipeline Integrity Working Group (PIWG) within CEPA formed a task group to support the initiative. The outlined approach was intended to have two main philosophical underpinnings: it must comprehensively support safe pipeline system operations and it must provide a practical mechanism for implementing a management systems approach for Facilities Iintegrity. The main challenge in developing a framework for a Facilities Integrity Management System lies in the broad range of equipment and system types that the management system must encompass. That is, equipment, in the context of Facilities Integrity Management, must encompass not only station equipment (such as rotating equipment, valves, meters etc.,) but also categories such as high pressure station piping and fuel lines. Further, there was the recognition that Operators already have an array of tools, processes and techniques in place to manage their various equipment and systems. In light of these observations, the Recommended Practice describes a framework that uses major equipment types as a key differentiator. This is an approach that can be easily aligned with existing corporate computerized maintenance management systems (CMMS) such as SAP™ or Maximo™. Once the equipment categorization has been established, the Recommended Practice then provides guidance regarding the specific requirements that should be addressed for each equipment category based on the framework in CSA Z662-11 Annex N. Specific suggestions are provided in the areas of: alignment with corporate goals and objectives, scope, definitions, performance metrics, risk assessments, competency of personnel, change management as well as documentation. The approach also maximizes the opportunity to leverage existing systems and processes to the extent possible. Overall the Recommended Practice should provide operators with a practical way to achieve a greater degree of rigor and alignment of facilities integrity management while ensuring detailed study and analysis is focused in the most appropriate areas. Copyright © 2014 by ASME.


Li Z.,University of Calgary | Dooley C.,Alliance Pipeline Ltd. | Cheng Y.F.,University of Calgary
NACE - International Corrosion Conference Series | Year: 2013

With the increasing use of high density polyethylene (HDPE) pipes in enhanced oil recovery process, environmental stress cracking (ESC) poses a threat to the integrity of pipes in alkali surfactant polymer (ASP) flooding. In this work, the ESC susceptibility of three types of HDPE material was investigated by ASP soaking, tensile testing, pre-notched specimen stressing tests and surface characterization. The results demonstrate that the susceptibility of HDPE to ESC depends on the ASP concentration, stress and the type of materials. The ASP solution soaking decreases the elongation of the material, especially at an elevated temperature. Furthermore, the percentage of the cracked specimens over the total number of specimens in ESC tests increases with the ASP concentration. The PE 100+ has the highest resistance to ESC compared to two other HDPE materials. PE 100+ exhibits a higher crystallinity and disentanglement energy than 4710 and 3608. The failure specimens exhibit swelling phenomenon and the formation of crazes on the specimen surface. ©2013 by NACE International.


Schapira D.O.S.,Alliance Pipeline Ltd
Proceedings of the Biennial International Pipeline Conference, IPC | Year: 2014

Alliance Pipeline operates an integrated Canadian and U.S. high-pressure, rich natural gas transmission pipeline system. Rich natural gas pipelines are unique in that the product transported in these pipelines contains greater amounts of higher molecular weight hydrocarbons than would be transported in a dry natural gas pipeline. The specifications for gas quality however are very similar and require the product to contain less than sixty five mg/m3 water, no free liquids and/or objectionable materials such as bacteria, ashphaltene, gum, etc. The acid gases, carbon dioxide and hydrogen sulphide, are also required to be below certain values (see Table 1). Corrosion is not expected to occur under these conditions due to the lack of free water available for the development of an electrochemical corrosion cell. However, there are instances where the gas quality may vary and this gas enters facility piping for short periods of time. A method has been developed by Pipeline Research Council International (PRCI) to determine the internal corrosion susceptibility for dry gas natural gas there are currently no industry pipelines but accepted models which determine the internal corrosion susceptibility for high energy natural gas (HENG) pipeline systems. Accordingly, it is important for operators of pipelines with high energy natural gas (HENG) to collect and analyze these off specification events and develop a method to determine the relative impact on internal corrosion susceptibility. It is perhaps more important for operators to use this method to develop a strategy to prioritize facility piping for inspection and confirm the absence of internal corrosion. An Internal Corrosion Susceptibility Assessment (ICSA) method has been developed for HENG which considers off specification water, carbon dioxide, and hydrogen sulphide contents in the HENG. The analysis has been enhanced to also consider low temperature operation and hydrocarbon dew-point variations. The model has been effectively trialed over the last number of years to prioritize inspections and has been further tested against PRCI research and models developed for dry gas internal corrosion susceptibility. All internal corrosion models need to identify free water as prime contributor to susceptibility, thus the subject model is considered adaptable to other gas pipeline systems. This paper discusses the methods used to develop the model, the challenges encountered and results of the field inspections conducted. Copyright © 2014 by ASME.


Demers D.,Alliance Pipeline Ltd. | Bhatia A.,Alliance Pipeline Ltd.
Proceedings of the Biennial International Pipeline Conference, IPC | Year: 2014

Alliance Pipeline (Alliance), an integrated Canadian and U.S. high-pressure, high-energy natural gas transmission pipeline system, is committed to the development and application of best practices for the full lifecycle of its pipeline system. Currently, there are several publications which individually set out minimum pipeline separation requirements, and discuss considerations for establishing an appropriate separation distance between adjacent pipelines or other buried structures sharing the same right-of-way (RoW). Alliance has reviewed these existing publications, and has consolidated the requirements, guidance, and best practices discussed therein for application in its own company practices. This paper summarizes the review and consolidation of these requirements, guidance, and best practices. Copyright © 2014 by ASME.


Reed M.,Alliance Pipeline Ltd. | Sahney R.,PBoK Technical Training Ltd. | Skibinsky D.,Alliance Pipeline Ltd.
Proceedings of the Biennial International Pipeline Conference, IPC | Year: 2014

Alliance Pipeline, (Alliance), an integrated Canadian and U.S. high-pressure rich natural gas transmission pipeline system, conducts Engineering Assessments for a variety of reasons related to integrity activities such as investigative digs, right-of-way crossings, encroachments and program review; however, the need for a consistent and systematic approach to perform work of this nature was identified. As such, the company launched an initiative to develop a structured approach for undertaking, reviewing and approving Engineering Assessments. The specific challenge in developing a framework for conducting Engineering Assessments is twofold: the framework must be scalable, to address a broad range of situations, while remaining practical to use and understand. In light of these requirements, Alliance chose to adopt a "Tiered" approach to identifying requirements associated with each engineering assessment. The Tier of the Engineering Assessment is defined based on two primary factors: the complexity of the analysis (i.e., whether the methodology of the analysis is well established or not) and the nature of the underlying assumptions (i.e., whether the assumptions associated with the analysis are within established parameters). Once the appropriate Tier has been selected, the framework then provides guidance regarding the specific requirements in the areas of: responsibilities and qualifications of individuals for preparation, review and approval of the assessment as well as documentation. The implementation and use of the structured approach was intended to ensure the Engineering Assessments undertaken within pipeline integrity were technically sound, while recognizing that a broad range of technical complexity, skill level and decision making are associated with Engineering Assessment. Overall, this approach will allow Alliance to achieve a degree of uniformity of its Engineering Assessments in order to manage risks effectively, while addressing the needs of a broad range of scenarios that rely on the methodology. Copyright © 2014 by ASME.

Loading Alliance Pipeline Ltd. collaborators
Loading Alliance Pipeline Ltd. collaborators